Enhanced hydrocarbon well blowout protection

ABSTRACT

Protection at a hydrocarbon well is enhanced by placing a blowout preventer over a well head. An adapter is connected to the blowout preventer. The adapter includes a valve that when turned off prevents non-production flow from the blowout preventer to a riser pipe.

RELATED APPLICATIONS

This application is a continuation application of U.S. patentapplication Ser. No. 13/151,669, filed on Jun. 2, 2011, which claims thebenefit of the following prior filed co-pending provisionalapplications: Provisional Patent Application Ser. No. 61/350,803, filedon Jun. 2, 2010; Provisional Patent Application Ser. No. 61/352,385,filed on Jun. 7, 2010; Provisional Patent Application Ser. No.61/357,519, filed on Jun. 22, 2010; Provisional Patent Application Ser.No. 61/362,055, filed on Jul. 7, 2010; each of which is herebyincorporated by reference in their entireties.

BACKGROUND

High pressure gas and oil deposits underground can explode through anoil well, gushing oil and gas into the environment, causing explosionskilling people, and inflicting tremendous damages to the environment andwild life. Such risks to human and environment though not limited tooff-shore wells are particularly severe and difficult to manage at deepocean off-shore sites. Case in point is the Deepwater Horizon drillingrig explosion that occurred Apr. 20, 2010 at the Macondo prospect oilfield in the Gulf of Mexico. The explosion resulted in the sinking ofthe rig, 4.9 million barrels of crude oil spewed into the ocean, 50billion cubic feet of methane gas spewed into the environ, and 2 millionbarrels of dispersants injected into the sea. Many estimated that theDeepwater Horizon disaster has caused damages in the order of a hundredbillion US Dollars, and inestimable further damages yet to unfold.

A conventional blowout preventer (BOP) used in hydrocarbon wells is acostly and massive contraption. The one used at the Macondo Well of theDeepwater Horizon disaster was about 53′ high.times.16′.times.16′ wideand weighing 300 tons. It is installed atop a well head with anapproximately 36″ flange connection to a well pipe about 20″ indiameter. A blowout preventer is a complex multiple-stage pipe-shearingand ramming device powered by batteries, controlled electrically viaelectrical wiring and electronic communications circuitry between theblowout preventer and the drilling rig, all of which may fail whenencountering hostile conditions such as fire, explosion, blowout, andhuman error. In the case of the Deepwater Horizon disaster, the blowoutpreventer's electrical components failed at the very beginning. Attemptsto mechanically activate the pipe-shearing and pipe-ramming devicesusing deep-sea robots also failed because the drill pipe remaining inthe blowout preventer jammed these devices. In addition, the blowoutpreventer was listing 12 to 16 degrees risking a catastrophic toppling.Postmortem examination of the blowout preventer showed extensivecorrosion. There was no access to the well head and the well below theblowout preventer, and no means to remove the damaged blowout preventerbefore the well was sealed through a five month long conventional“bottom kill” procedure, during which a relief well was drilled toaccess the bottom of the problem well to plug it. If the casing systemof the well is compromised, stemming the blowout hydrocarbon flow at orabove blowout preventer would result in high pressure hydrocarbonbreaching grounds below the sea floor and escaping through the seafloor.

Conventional remedial methods were tried and failed during the manymonths following the Deepwater Horizon drilling rig explosion. Duringthat time, the oil spilled and the dispersant released into the Gulf ofMexico traveled wide with the gulf current, causing disastrousenvironmental and commerce damages. The conventional methods tried andfailed included the use of coffered domes and top hats which are massiveup-side-down funnels with a riser pipe at the top that were lowered overthe hydrocarbon spewing broken pipe sections in hope of capturing thespewing hydrocarbon. Unfortunately frozen hydrate formed to block theriser pipe.

Another method that was tried and failed was the insertion of a thinnergood pipe into the damaged pipe section in an attempt to capture some ofthe oil and gas flow. Unfortunately the hydrocarbon pressure enlargedthe broken gap at the pipe section near the top of the blowout preventerand spewed out there instead.

Another method that was tried and failed was the pumping golf balls,tire shreds, ropes, knots, and other junk and mud into the blowoutpreventer, hoping to plug the pipe in the blowout preventer to stem themassive hydrocarbon flow. Unfortunately the high pressure hydrocarbonflow spewed out the junk with it.

Another method that was tried and failed was a hat-like contraption,called a lower marine riser package (LMRP), with a wide open bottom anda pipe at the top. This was placed loosely fitting over the cut pipeopening at the top of blowout preventer, hoping to catch some of thespewing hydrocarbon. Unfortunately, more than 75% of the spewinghydrocarbon was reflected off the hat-top of the LMRP and ejected downinto the surrounding ocean.

SUMMARY

Protection at a hydrocarbon well is enhanced by placing a blowoutpreventer over a well head. An adapter is connected to the blowoutpreventer. The adapter includes a valve that when turned off preventsnon-production flow from the blowout preventer to a riser pipe.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows an anchoring infrastructure for a blowout preventer withpiers drilled into bedrock in accordance with an embodiment of thedisclosure.

FIG. 2 shows an alternate example of anchoring piers with pier-anchoringdiscs that anchor the piers in case the location has deep sediment oruneven sea floor.

FIG. 3 and FIG. 4 show a flange sealable capping and flow capturingdevice, sealable hydrocarbon capturing pipe adaptor (SHCPA) with atubular body and flange connectors, an optional flow control valve, andan optional side branch adaptor in accordance with embodiments of thedisclosure.

FIG. 5 shows a pipe plugging assembly with a flanged pipe adaptor and aflow-control valve in accordance with an embodiment of the disclosure.

FIG. 6 and FIG. 7 show use of a reaming device to ream a smooth sealablesurface in the pipe that mates with the plug shown in FIG. 5 inaccordance with an embodiment of the disclosure.

FIG. 8 shows a pipe sleeve lined with sealable elastomeric material usedto make a sealed connection between the pipe and the capping deviceillustrated in FIG. 3 in accordance with an embodiment of the presentdisclosure.

FIG. 9 shows a well head protection base plate composed of twoself-sealing half plates installed at a well head at the sea floor levelin accordance with an embodiment of the present disclosure.

FIG. 10 shows a hydrocarbon containment and collection chamber inaccordance with an embodiment of the present disclosure.

FIG. 11, FIG. 12 and FIG. 13 show several electrically and hydraulicallyoperable pipe squeezers in accordance with an embodiment of the presentdisclosure.

FIG. 14 shows a roaming pipe squeezer in accordance with an embodimentof the present disclosure.

FIG. 15, FIG. 16, and FIG. 17 show various assemblies that can replace aconventional blowout preventer in accordance with an embodiment of thepresent disclosure.

FIG. 18, FIG. 19 and FIG. 20 show multi-port branched pipe adaptors(MPBPA) in accordance with an embodiment of the present disclosure.

FIG. 21 shows a device driver deploying well monitoring and inspectiondevices, pipe repairing assembly, and well plugging devices inaccordance with an embodiment of the present disclosure.

FIG. 22 and FIG. 23 show a multi-port branched pipe adaptor (MPBPA)mounted above, and below a blowout preventer in accordance withembodiments of the present disclosure.

FIG. 24, FIG. 25 and FIG. 26 show pipe assemblies using a one-way checkvalve to prevent up-flow as well as various configurations of suchone-way check valves in accordance with embodiments of the presentdisclosure.

DESCRIPTION OF THE EMBODIMENTS

This description herein incorporates by reference all the subject matterdisclosed in provisional application No. of 61/350,803, filed on Jun. 2,2010; provisional application No. of 61/352,385, filed on Jun. 7, 2010;provisional application No. of 61/357,519, filed on Jun. 22, 2010;provisional application No. of 61/362,055, filed on Jul. 7, 2010.

Hydrocarbon well safety is enhanced by protecting a blowout preventer,and its connection to a riser pipe and a well head. In variousembodiments, infrastructure is anchored to protect well components andto deploy assembly and operations. A flange sealable capping andhydrocarbon capturing pipe adaptor is used to cap an oil and gas spewingBOP and capture the hydrocarbon flow, a sealing plug with a sealablepipe adaptor is used to seal a broken pipe sits atop the BOP and tocapture the spewing blowout hydrocarbon flow. A base-plate is mounted onthe sea floor to protect the well head and anchor the BOP. A containmentand protection chamber with a venue for hydrocarbon extraction ismounted on the base plate. A safer and more effective blowout preventeris presented that replaces a conventional blowout preventer. Amulti-port branched pipe-adapter (MPBPA) can be mounted above and belowa blowout preventer to improve well access and safety, and to capturehydrocarbon flow in case of a blowout event. A MPBPA enables fullcollection of the blowout hydrocarbons while conducting well monitoring,inspection, repair, plugging, or “bottom killing” the well from the wellthrough the MPBPA after a blowout event.

Pre-event fabrication and installation of devices and apparatusdescribed in this disclosure will enhance well safety, help preventblowout events, enable quick and effective remedial responses, andminimize risks and damages from a blowout event. Additional benefitsinclude prevention of accidental damages or unauthorized access to theblowout preventer, well head, and wellbore, securing wellbore accessregardless of the blowout preventer condition, the ability to remove andreplace a problematic blowout preventer, and the ability to separatelycapture and collect methane gas from oil.

The concepts illustrated herein are extendable by those skilled in thearts to a multitude of variations, combinations and applications in theoil and gas industry including exploration, production, and service andmaintenance operations not specifically discussed in this application.

Disclosed embodiments are applicable to all phases of a well creationand operations. Even though the embodiments are illustrated with avertically drilled off-shore well, many disclosed elements are alsosuited for non-vertically drilled wells and on shore wells.

FIG. 1 shows an anchoring infrastructure for a blowout preventer 306. Toform an anchoring infrastructure 100, anchoring piers 101 are driveninto the sea floor 90 through a sediment layer 91 into bedrock 92 at asuitable distance from a well. Mounting and positioning devices 102mount a platform 103 onto anchoring piers 101 to support and protectwell components or to deploy various assemblies or well operations.Anchoring infrastructure 100 also serves to position and align theassembly that includes blowout preventer 306, platform 103, pipes,various apparatus and components in anchoring infrastructure 100.

For pre-event installation, platform 103 incorporates a via forconnecting BOP 306 to a riser pipe 104. A BOP to riser pipe flange andclamp 105 is mounted above a blowout preventer 306 and platform 103. Aflange mounted flexible pipe section 210 can be mounted below riser pipe104 and on top a sealable hydrocarbon capturing pipe adaptor (SHCPA) 200as described in FIG. 3 or a MPBPA 500 as described in FIG. 18, which ismounted to the top flange of BOP on top platform 103. Platform 103anchors well components above it, and protects well components below itincluding blowout preventer 306, and well head 303.

If riser pipe 104 falls with a sinking rig, as occurred during theDeepwater Horizon disaster, riser pipe 104 may break anywhere betweenthe rig (not shown) and the flexible pipe section, or at worst at thecomponent immediately above platform 103. The flexible pipe sectioncushions the drag from the fallen riser pipe and protects SHCPA 200 orMPBPA 500. Platform 103 and everything below, including blowoutpreventer 306 are protected and most likely will remain intact.Alternately, platform 103 can be located immediately below the topflange of SHCPA 200 or MPBPA 500 connecting to the top of BOP 306, withonly the flexible pipe and riser pipe above platform 103. If eitherflexible pipe 210 or riser pipe 104, or both are damaged, they can beeasily removed and replaced.

A well head protection base plate 300 is shown mounted at the sea floorlevel. A containment and protection chamber can be mounted on base plate300, as illustrated in FIG. 10 where containment and protection chamber310 is mounted on base plate 300. Containment and protection chamber 310also serves to protect the well and to capture hydrocarbon flow leakingfrom the well in case of a blowout or an accident.

A blowout preventer support framework can be mounted to anchor on baseplate 300 and positioned immediately below blowout preventer 306 so thatthe weight of blowout preventer 306 sits on the framework. Alternately,the framework can be anchored to anchoring piers 101. This isillustrated in FIG. 22 where is shown a blowout preventer support andisolation framework 760 upon which a blowout preventer 306 sits.

As shown in FIG. 1, for example, platform 103 can be made with anapparatus mounting hole 110 used for mounting various devices andapparatus. This allows platform 103 to function as a general purposeoperation launching counter-pressure platform as needed for deployingand mounting devices or apparatus used in response to a high pressureblowout hydrocarbon flow. For example, operations utilizing platform 103might include an operation to cap and capture the blowout hydrocarbonflow, an operation to squeeze shut or cut off damaged riser pipe, anoperation to mount an encapsulation or containment and protectionchamber to enclose the well and contain and capture leaking hydrocarbonflow, an operation to remove pipes stuck in the blowout preventer, andan operation to mount an assembly driving string for launching sensors,plugs, and repair assembly into the well.

FIG. 2 shows additional detail of pier anchoring discs 106 located atsea floor 90 where piers 101 penetrate sea floor. Pier anchoring discs106 have through-holes through which piers 101 are driven into the seafloor 90. Pier anchoring discs 106 help anchor piers 101, reducing thedepth into which piers 101 need to be driven into the sea floor 90.These pier anchoring discs are especially helpful when the sedimentlayer is deep, or when the geography around the well head is not flatover an adequately large area.

FIG. 3 shows a sealable hydrocarbon capturing pipe adaptor (SHCPA) 200that can be used for capping a problem well leaking from above theblowout preventer, and to collect and harvest the hydrocarbon flow to acollection facility. Sealable hydrocarbon capturing pipe adaptor SHCPA200 has a flange 201 for connecting to blowout preventer 306. A flange203 allows connection to a hydrocarbon collection pipe 204 or a riserpipe containing a hydrocarbon collection pipe. An optional flow controlvalve 202 can be included to provide additional operational flexibility.At least one branch can be added to SHCPA 200. The top of SHCPA 200 canbe capped, as shown in FIG. 4, which also shows 2 side branches. Morethan 2 branches can be added.

In a normal operation of an oil well there should never be hydrocarbonpresence in the well space outside of a production pipe. Hydrocarbonpresence there is a rogue hydrocarbon presence and indicates trouble.The legitimate fluids in this space are drilling fluids (also calleddrilling mud), sea water and occasionally cement slurry. This spaceincludes the casing pipe string below the well head, the BOP core, andthe riser pipe outside of the production pipe within. Before theproduction pipe is installed, there should be no hydrocarbon presence inthe well all the way from the low end of the casing pipe through the BOPand riser pipe up to the rig. When sensing a hydrocarbon up flow fromthe bottom of the well—which pushes drilling fluid up at the top end,more drilling mud must be pumped down to increase counter pressure toexpel the rogue hydrocarbon back down to the reservoir. During drillingphase, a relatively small diameter drill pipe string (passing throughthe center of a riser pipe, the BOP tubular core, and the casing pipe)pumps down drilling fluid into the well bore to cool the drill headattached to the drill pipe through a collar at the bottom end of thedrill pipe and circulate the formation debris such as rocks, sand andsoil up with the drilling fluid through the well bore, the casing pipe,the BOP tubular core and the riser pipe, to the drilling rig. The debrisis filtered out, and the drilling fluid re-circulated down to the wellbore. During the drilling process, the well bore size is progressivelyreduced and progressively smaller diameter casing pipe strings areinstalled into the well bore to line the well and isolate the earthformation from the well. Typically the last two layers of casing pipestrings reach the reservoir. The annular space between the layers andthe core space of the inner most casing pipe are filled with drillingfluid. The bottom end of the annular space is sealed from the reservoirwith cement. The bottom of the casing pipe is sealed from the reservoirwith a “cement shoe.” Heavy drilling fluid column inside the wellborecounter balances the hydrocarbon pressure in the reservoir. Above a safelevel of drilling fluid column, sea water is used to fill the space. Theproduction pipe is installed inside the inner most casing pipe during a“completion” process sometime after the drilling process is completed.The production pipe assembly goes from the rig, pass through the riserpipe, BOP core, through the center of the casing pipe down to thereservoir. During a production mode, the usually hot hydrocarbons aremanipulated to flow up the production pipe to the rig at a controlledrate, which is production flow. Every other flow that happens in thesepipes is a non-production flow. The annular space in the riser pipe, theBOP core, and the casing pipe outside the production pipe is filled withdrilling fluid or sea water, and sometimes injected nitrogen gas tobalance pressure and keep the well bore at an appropriate temperaturerange.

If sealable hydrocarbon capturing pipe adaptor SHCPA 200 is notinstalled pre-event, it can be mounted to blowout preventer 306 using anundersea robot such as a Remotely Operated Undersea Vehicle (ROV).Hydrocarbon collection pipe 204 can then be attached to flange 203. Flowcontrol valve 202 is kept open through the process to minimize resistivepressure from the blowout flow.

Alternatively, sealable hydrocarbon capturing pipe adaptor SHCPA 200 canbe attached to a riser pipe at sea level, and lowered with the riserpipe to blowout preventer 306 to make a flange-to-flange connection toblowout preventer 306 at flange 201 using an ROV. Flow control valve 202can be kept open when attaching flange 201 to the blowout preventerflange to minimize resistive pressure from the blowout flow. The valvecan be closed to stop the hydrocarbon flow when desirable—for example,when threat of storm mandates a connected rig or an oil storage ship toleave for safe harboring, or when an oil storage ship is full and readyto disengage.

An optional branch 205 with control valve 206 and collection pipe flange207 can be added as an additional collection channel or as a divertingchannel when desirable. For example, after sealable hydrocarboncapturing pipe adaptor SHCPA 200 is attached to blowout preventer 306,diverting the flow to side branch 205 helps clear the visibility andresistive pressure for attaching hydrocarbon collection pipe 204 to theassembly at flange 203. Another example is when a storage ship is todisengage and another ship engaged, the side branch can be used todivert the hydrocarbon flow to the new ship before valve 202 is shut offto disengage the first ship. Side branch adaptor 205 includes pipeconnecting flange 207 and control valve 206. Multiple side branches areincorporated for operational needs and flexibility.

When SHCPA 200 is to be used for pre-event installation, a pressure orhydrocarbon sensor (or both), sensor assembly 208 is added to closecontrol valve 202 when hydrocarbon presence is detected. The closing ofcontrol valve 202 will divert the rogue hydrocarbons to branch 205,which is further piped to a storage unit at seafloor while remedialaction is sought, or to wait for a suitable time to transport to acollection facility at sea surface. A collection facility is anycombination of the following: a ship, a tanker, a rig, a processingfacility, a storage unit or a storage tank, or anything that collects.And it can be located at or near the sea surface (hence forth as at seasurface) or at or near sea floor (hence forth as at seafloor). A storageunit is any combination of the following: a storage tank (or multiplestorage tanks), a storage tank without outlet, or a storage tank with aninlet and an outlet. The storage unit can be further equipped with amanifold as shown in FIG. 17 to fill a storage tank (or multiple storagetanks) of a size convenient for transport from seafloor to a collectionfacility at sea surface. Additional optional branches can be added to205 to provide more functions. A flexible pipe section with top andbottom flange connectors can be added to SHCPA 200 as desired, forexample, for the purpose of shock absorption or drag isolation.

If after a blowout event a damaged riser pipe is cut at above theblowout preventer and cannot be easily or safely removed from theblowout preventer, a plugging device, such as a pipe plug 235 shown inFIG. 5, can be used to plug the cut pipe, at least until the cut pipe isremoved from blowout preventer 306.

As shown in FIG. 5, pipe plug 235 incorporates a flange 226 forconnecting to a hydrocarbon collection pipe 239. Plug 235 can be used toplug a cut pipe 238, and capture hydrocarbon flow through hydrocarboncollection pipe 239 connected to flange 226. Pipe plug 235 can be usedin conjunction with an optional assembly handling and counter pressureapplication accessory 210 to increase the area for handling pipe plug235 and where force can be applied to help drive pipe plug 235 into theopening of cut pipe 238. When needed, the assembly handling accessory210 can be mounted on the general purpose counter pressure platform 103anchored to anchoring infrastructure 100 shown in FIG. 1. A flow controlvalve 225 controls the hydrocarbon flow, and hydrocarbon collection pipe239 connected to flange 226 harvests hydrocarbon flow to a storage ship,a storage terminal, or a temporary storage unit at seafloor. When and ifthe ship has to disengage, flow control valve 225 can be closed off ifso desired. Flow control valve 225 also enables controlled pressurerelief during and after the plugging process.

A pliable pipe sleeve lined with pliable sealing material can be used tomake a sealed joint between sealable hydrocarbon capturing pipe adaptorSHCPA 200 shown in FIG. 3 and cut pipe 238. A reamer 241 can be used togenerate a smooth sealable plug-mating surface at the opening of cutpipe 238, as illustrated in FIG. 6 and FIG. 7. FIG. 6 shows a side crosssectional view and FIG. 7 shows a top cross-sectional view of reamer 241having a rotating cone 236 and an abrasive surface 237.

FIG. 8 shows a pipe sleeve 256 lined with pliable material 252. Forexample pliable material 252 is an elastomeric material reinforced withpara-aramid synthetic fiber or some other pliable material with suitablechemical and physical characteristics. Pipe sleeve 256 is furtherequipped at the top with a flange connector 255 to form a sealedconnection with the bottom flange 201 of sealable hydrocarbon collectionpipe adaptor SHCPA 200. A pipe fastener 254 is used for tightening pipesleeve 256 to cover and seal an imperfect pipe 246. A slightly angledcone surface 253 facilitates a tight seal.

As shown in FIG. 9, whole base plate 300 is formed, for example, fromhalf plates 301 and 302 tongue-in-grooved to form an oil sealedconnection with each other. Base plate 300 is installed on the sea floorto surround and protect well head 303. Base plate 300, with its largehorizontal surface resting on the seafloor is self anchoring.Additionally, through-holes can be added to the base plate toaccommodate anchoring piers to drive through these holes into the seafloor to help anchoring the piers. As shown in FIG. 1, base plate 300and anchoring piers 101 which are driven through holes in 300 into thebase rock mutually anchoring one another's stability. Alternately, baseplate 300 can be an independent anchoring apparatus. A sealing groove304 supports a full enclosure containment and protection chamber. Atwo-piece well head brace 305 forms an oil tight seal with base plate300 around well head 303. Well head brace 305 is inserted into a centerwell-head through-hole of base plate 300 to brace well head 303. Wellhead brace 305 can be removed for well head inspection. In aconventional well, blowout preventer 306 is mounted directly on top ofwell head 303 without benefit of a support structure. Base plate 300 cananchor and support a frame work upon which blowout preventer 306 sits.Independent of anchoring infrastructure, SHCPA 200 described in FIG. 3can be inserted between BOP 306 and riser pipe 204 as shown in 250,which in itself substantially enhance well safety.

If base plate 300 is installed before blowout preventer 306 is mounted,base plate 300 can be installed as a whole plate with a centerthrough-hole for well head 303 and well head brace 305.

FIG. 10 shows a containment and protection chamber 310 deployed overblowout preventer 306. For deploying after a blow out event to contain,capture, and harvest the blowout hydrocarbon flow, containment andprotection chamber includes a flanged pipe adaptor 314 and a controlvalve 312. Containment and protection chamber 310 is placed over theblowout preventer 306 on base plate 300 and with a damaged riser pipe317 already cut away from it.

A hydrocarbon collection pipe can be mounted on pipe adaptor 314 to pipethe captured hydrocarbon flow from containment and protection chamber310 to a storage ship, a collection terminal, or a temporary storageunit at sea floor near the well. Since base plate 300 and containmentand protection chamber 310 must be larger than blowout preventer 306 inorder to adequately surround blowout preventer 306, and both are to bemade of heavy and durable material, it is anticipated that anchoringpiers 101 (shown in FIG. 1) and a chamber-top counter pressure platform103 may not be needed and are optional in this embodiment. A via at thecenter of the top of chamber 310 is not needed for post-event emergencyinstallation, and chamber 310 needs to be taller than the blowoutpreventer.

For pre-event installation to enhance safety, containment and protectionchamber 310 is additionally equipped with a via 315, through which theblowout preventer top pipe feeds through to the top of containment andprotection chamber 310 with a blowout preventer top flange 316 sits ontop of containment and protection chamber 310, and a riser pipe 317 isconnected to flange 316 for conducting normal operation. An optionalback up cut-and-seal slider assembly 318 as illustrated in FIG. 11 canbe mounted on top of containment and protection chamber 310 to cut andseal a damaged riser pipe in case of an event and a blowout preventerfailure. A pipe squeezing assembly can also be added on top of chamber310 for redundancy. An optional door 335 permits ROV access to blowoutpreventer 306 and well head 303. Alternately a flexible pipe (flex pipe)can be inserted between the top flange of the blowout preventer (BOP)306 to feed through via 315 with the top flange of the flex-pipeanchored and sit on top chamber 310, and connected to riser pipe 317.The advantage of this arrangement is that the containment and protectionchamber of the same height can be used for both pre- and post-eventinstallation. The flex-pipe extends the BOP pipe to adapt to the tallerchamber 310, while further insulates BOP 306 from mechanical shockscoming from outside of chamber 310. Additional safety benefit of acontainment and protection chamber 310 is that it isolates blowoutpreventer 306 and well head 303 from undesired open access prone toaccidental marine life collision or sabotage. Ideally, a sealedhydrocarbon collection pipe adaptor SHCPA 200 or a MPBPA 500 is addedbetween containment and protection chamber 310 and riser pipe 317 tofurther enhance operational flexibility and safety.

FIG. 11 shows views of pipe slicer assembly 318 and block pipe squeezerassembly 340 to be mounted on and anchored to the top of containment andprotection chamber 310 or a general purpose assembly mounting andanchoring platform such as platform 103 shown in FIG. 1. Pipe slicerassembly 318 is a cut and seal slider, where assembly tracks 319 mountedon both sides of a target object 321 guide blade 320 to cut targetobject 321. When blade 320 completes the cut and traverse along tracks319 pass target object 321, seal cap 322 located behind blade 320 dropsdown to seal the cut pipe. The drop is facilitated by levers 324. Pipesqueezer assembly 340 includes an anchor block 341 and rails 342 and343. A ramming block 344 presses toward anchor block 341 and squeezes atarget object such as an oil pipe 345 flat and shut.

FIG. 12 shows a top sectional view of a block and piston squeezer, whereboth blocks 351 and 352 are mounted and anchored to the top ofcontainment and protection chamber 310 or a general purpose assemblymounting and anchoring platform such as platform 103 shown in FIG. 1. Apiston 353 is tightened to squeeze oil pipe 355 flat and shut.

FIG. 13 is a conceptual drawing of a multi-stage pipe squeezer whichreduces mechanical stress on a squeezed pipe 365. A squeeze stagecomprised of squeezers 361 and 371 and a squeeze stage comprised ofsqueezers 362 and 372 squeeze pipe 365 partially and progressively shut,until a squeeze stage composed of squeezer 363 squeezes pipe 365 fullyshut. Any number of stages can be constructed to optimize the shut-offspeed and minimize potential for pipe breakage.

A pipe slicer or a pipe squeezer such as any of the ones shown in FIG.11, FIG. 12 and FIG. 13 can be incorporated with containment andprotection chamber 310 in multiple stage stacks, or stack mounted on ageneral purpose assembly mounting and anchoring platform 103 asdescribed in FIG. 1, to replace or back up the functions of a blowoutpreventer.

FIG. 14 shows a mating pair of a roaming pipe squeezer that can bedeployed with an ROV to squeeze shut any pipe section 385. Blocks 381and 382 (with or without a piston) are deployed to the opposite sides ofa pipe section and assembled together. Blocks 381 and 382 and a pistonare hydraulically operated to come together to squeeze shut pipe section385. Rods 383 and 384 are mounted on blocks 381 and 382, as shown inFIG. 14. Rod 383 is inserted through a hole in block 382. Rod 384 isinserted through a hole in block 381, as shown. Tightening disks 386 and387 parked on blocks 381 and 382 are then mounted onto rods 383 and 384,and hydraulically operated to tighten blocks 381 and 382 against pipe385. Optional piston 388 further assists the pipe squeezing.

Conventional hydrocarbon kick detection is conducted on board a drillingor production rig by analyzing measurement of indirect indicators suchas drilling mud pit volume change, fluid out-flow of the well comparedto fluid pumped into the well through the drilling pipe, or drill pipefluid pressure measured at the pump which is difficult to interpretbecause so many different factors can affect that pressure. Theseindicators unfortunately can be masked by operational activities.Furthermore the indicators are then displayed for human interpretation.These difficulties compounded by the time lag between a dangeroushydrocarbon kick occurrence at the well bore and the detection ofindirect indicators make timely issuance of a command to activate aconventional BOP difficult to achieve. When and if a conventional BOP isactivated, its annular seals can seal the tubal core chamber of the BOP,but can not seal a pipe present in the BOP core chamber. Its blindshearing ram can shear a pipe present in BOP, but can not shear pipejoints, and can not shear an off-centered pipe. The rubberized materialused in the rams and the annular seals in the conventional BOP, as wellas the movable rams that join with the tubal members to form the tubularcore chamber of BOP are not designed for extended hydrocarbon exposureand prone to corrosion and leak. Embodiments described below providesolutions to these problems.

A direct hydrocarbon-kick detection and automated kick management systemusing a full featured SHCPA 200 shown in FIG. 3 and described in [0037]through [0038] can be retro-fitted between conventional blowoutpreventer 306 and riser pipe 204 as shown in 250 of FIG. 9. Similarly,such system can be incorporated into a new blowout preventer 399 asdescribed in FIG. 15, 440; or, alternately installed between well head303 and a conventional blowout preventer 306 using MPBPA 500, asillustrated in system 710 in FIG. 22. Furthermore, with a pressuresensor installed in a sensor assembly 208, the diversion branch in SHCPAand MPBPA can be used to relieve over pressured drilling fluid presentin an annular space between the inner-most casing pipe (also called theproduction casing pipe) and the production pipe to manage and regulatethe difficult annular pressure buildup problem during hydrocarbonproduction mode. The branch can be further fitted with a bladder tostore the over-pressured over-flow fluid, and to push back the fluidwhen the annular pressure drops. One example of such a bladder is aballoon bladder. Similarly, the annular pressure between two casingpipes can be regulated through a branch pipe as well. This can beaccomplished by equipping a branch with a pressure sensor, andconnecting the branch to the annular space and a fluid overflow bladder.The assembly regulates pressure in the annular space by conducting overpressured drilling fluid out of the annular space into the overflowbladder. When the pressure reduces in the annular space, the fluidreturns back to the annular space.

FIG. 15 shows a blowout preventer 399 with a simpler, sturdier, and moreeffective design than conventional blowout preventer 306. Blowoutpreventer 399 includes a two level protection and support chamber 400mounted on well head protection base plate 300. A lower pipe section 403is made of stronger and thicker walls of hydrocarbon compatible materialthan an ordinary well pipe. A flange 404 at the bottom of blowoutpreventer 399 mounts to well head 303 at the flange 420. Pipe section403 extends through an upper level floor 402 of chamber 400 terminatingat a flange 405 resting on upper level floor 402 of chamber 400. Anupper well pipe section 406 is made of material that can be reliablysqueezed shut or cleanly cut and sealed. A flange 407 mounts to flange405 at the top of lower pipe section 403.

A multi-stage pipe squeezing stack 410 is composed of devices similarto, for example, any of those shown in FIGS. 11, 12 and 13. Anoff-setting multi-stage cutting and sealing stack 412 is mounted 90degrees from multi-stage pipe squeezing stack 410. Both stacks aremounted on upper level supporting floor 402 of protective chamber 400for support and anchoring. Upper level pipe 406 extends through theceiling of protective chamber 400 with a connecting flange 414 sittingat the top of the protective chamber 400, to be connected to a riserpipe 415 through a flange 416. Alternately, a SHCPA 200 or a MPBPA 500can be installed between BOP flange 414 and riser pipe flange 416. Doors430 can be installed on select sides of protective chamber 400 at bothlevels for access, maintenance and inspection.

Hydrocarbon kick detection and management system 440 can be incorporatedwith lower pipe section 403 as an additional safety feature notavailable in conventional blowout preventer 306. Hydrocarbon kickdetection and management system 440 includes a control valve 434, asensor assembly 431, a hydrocarbon diversion pipe 436 for conductinghydrocarbon kick flow to a safe distance for collection or storage, anda control valve 435 for pipe 436. Control valve 434 can be set to anormally open position to allow drilling mud and drill pipe to passthrough, and closes when detecting hydrocarbon presence to diverthydrocarbon to diversion pipe 436. Control valve 435 is normally closedto prevent drilling mud from entering diversion pipe 436, and opens whensensor 431 detects presence of hydrocarbon to divert the flow to astorage unit 439 in FIG. 16. A separate pipe outside of the blowoutpreventer can be used for accommodating drilling mud up-flow. Controlvalve 434 can then be a one-way valve set at a normally closed position,preventing any up-flow and allowing only down flow of drilling mud.Progressively more advanced kick management capability can be attainedby progressively adding the following components: an optional bleedvalve 432 to control the rate of hydrocarbon release to diversion pipe436; an optional oil and methane separator 438 equipped with oil pipe441 which can be extended with a flange connector 443 to lead to a oilstorage unit at seafloor or a collection facility at sea surface. Amethane pipe 442 which can be extended with a flange connector 445 tolead to a methane storage unit or a collection facility. Oil and gasseparator 438 can be constructed using a sufficiently strong filter thatallows gaseous methane to pass to methane outlet pipe 442, and filtersout oil to pass to oil outlet pipe 441. Alternately, separator 438 canbe accomplished by using a storage tank 439 and gravity separation, bylocating a gas outlet pipe 442 at a top location of the storage tank andan oil outlet pipe 441 at a bottom location of the storage tank, asillustrated in FIG. 16. Separating methane storage from oil at sea floorlevel allows each to be separately piped to separate storage units. Ahydrocarbon manifold 450 shown in FIG. 17 can be used to fill multiplestorage tanks 452 of a size suitable for handling and transport, eachhaving a valve which closes when the tank is filled. Manifold 450contains a battery pack, sensors, a control circuit, pipes and valves.The manifold 450 controls and conducts orderly filling of tanks 452 andorderly open and closing of valves. A docking unit 455 facilitatesremoval and replacement of tanks 452. Valve 453 closes when tank 452 isfilled to a desired level. Valve 454 expels pre-existing pressurebalancing liquid (e.g. sea water) in tank 452 as it is filled withhydrocarbon. The filled tanks can be removed and lifted to sea surfaceat a suitable time to transport to long term storage or processingfacility. Methane gas can be filled at seafloor level to a desiredcompression level, and further compressed or liquefied at a processingplant. Filled tanks are removed and replaced aided by an ROV. Oil outletpipe 441 can be piped to an oil tanker at sea surface at a safelocation, or piped to a temporary oil storage unit at the sea floor, orto manifold 450 to fill multiple storage tanks to be transported to thesea surface at a suitable time. The hydrocarbons from pipe 436 can alsobe piped to a storage unit at seafloor, or a collection facility at seasurface.

To accommodate presence of production or drill pipe inside Valves 434and 432, these valves are constructed in a self centering “iris shutter”style to close inward toward the center such that 434 seals around thepipe inside, and closes completely if no pipe is present. Optional bleedvalve 432 is set to partially close to allow controlled pass through ofthe high pressure hydrocarbon flow to diversion pipe 436. Details of aniris shutter valve are described later in FIG. 26. The casing pipes, theproduction pipe and the drill pipe can all be fitted with their ownsafety valves at a low portion of the pipes to defend againstthreatening hydrocarbon kicks from surging further up the pipes.

FIG. 18 shows a multi-port branched pipe adaptor (MPBPA) 500 having mainbranch 520 with a port 510 for well access or hydrocarbon capture, andat least one other branch 550 with port 551 for hydrocarbon capture ordiversion of over pressured well fluids. The top of port 510 is equippedwith a seal flange 503, which can seal mount to a riser pipe 530, securea drill pipe or an assembly driver string 540, or a riser pipecontaining a drill pipe or driver string, or a hydrocarbon collectionpipe. During normal operation, port 510 can serve as a hydrocarboncollection port. Optional valve 505 allows port 510 to open for variousoperations including for assembly driver string 540 to pass through, orto close to divert a blowout flow for improved visibility when desiredor needed before and during mounting of an apparatus or a pipe during ablowout flow. A hydrocarbon capture port 550 is equipped with a flange553 to secure, and seal mount to a hydrocarbon collection pipe assembly560, to further connect to a hydrocarbon collection facility such as astorage unit at the sea floor, or an oil tanker at the sea level tocollect and store the captured hydrocarbons. A flexible pipe sectionwith top and bottom flange connectors can be added to MPBPA 500 asdesired. The storage unit at seafloor may be further equipped with amanifold as shown in manifold 450 in FIG. 17 to fill multiple storagetanks of a size suitable for handling and transport to a collectionfacility at sea level. A tank docking station facilitates removal andreplacement of tanks.

An optional valve 555 allows shutting the hydrocarbon flow when needed.Sonar, ultrasonic or electromagnetic wave generation/inspection devicescan be mounted and run with assembly driver string 540. A BOP mountingport at the bottom of the main branch 520 of MPBPA 500 is equipped witha suitable flange 573 to form a sealed direct connection with a blowoutpreventer top flange 575. A pipe sleeve 256 as shown in FIG. 8, FIG. 19,and FIG. 20 having a flange 255 can be used for making a sealedconnection between MPBPA 500 and a damaged pipe 246 that can not beeasily removed from blowout preventer 306. Padded sealer pipe sleeve 256includes elastomeric material reinforced with para-aramid syntheticfiber or some other pliable material with suitable chemical and physicalcharacteristics covers damaged pipe 246 and fastened with fastener 254to provide a seal. The diameters of the ports of MPBPA 500 are close tothe diameter of the pipe that is spewing the hydrocarbon flow, so thatdeflection and reflection of the hydrocarbon flow is minimized. MPBPA500 can be modified to have two symmetrical hydrocarbon collection portsto weight balance the assembly, and to increase the rate and flexibilityin hydrocarbon collection. This is illustrated in FIG. 19. Many moreside branches can be added.

Methane gas volume expands rapidly to become more explosive anddangerous as it rises from the sea floor level toward the rig. It isdesirable to separate methane gas from oil, and pipe it away from thewell at a level closer to the sea floor to a storage tank, or togradually raise the pipe in a controlled manner to a methane gascollection facility. FIG. 20 shows a MPBPA 599 equipped with a pressuresensor and/or hydrocarbon detector, sensor assembly 592 installed at thelower end of the main trunk of MPBPA 599. When a high pressurehydrocarbon surge is detected, valve 593 automatically closes to diverthydrocarbons to branch pipe 550 which can be further piped to a storagetank at sea floor level. The storage tank can additionally serve as oiland gas separator as described in FIG. 16. Separator 596 allows methaneto pass to gas pipe 597, and oil filtered out to oil pipe 595, each isextended separately to a separate storage at seafloor or a collectionfacility at sea surface. Hydrocarbon or pressure sensor 592 can beadditionally fitted with a bleed valve 594, when sensor 592 detectshydrocarbon, it closes valve 593, and partially shuts the optional bleedvalve 594. Bleed valve 594 allows controlled hydrocarbon release intobranch pipe 550. Alternately, hydrocarbon kick detection and managementsystem can be installed in a blowout preventer as described in FIG. 15.

A multi-port branched pipe adaptor should be incorporated in all wellsystems at above a blowout preventer, below a blowout preventer, orideally both above and below a blowout preventer, or located inside anew blow out preventer as standard safety features.

FIG. 21 shows a device driving string 640 mounted through MPBPA 600.Device driving string 640 is used for running and setting devices forwell inspection, repair, and plugging from above or below blowoutpreventer 306. If a drill pipe or a device driver is broken off andremains in blowout preventer 306 and the well below, it should beremoved through port 670 before a new driving string is mounted. If thepipes are stuck in an unsuccessfully activated blowout preventer 306,the pipes and blowout preventer 306 need to be removed. An MPBPApre-installed below blowout preventer 306 enables the safe removal of adamaged or malfunctioning blowout preventer as further described below.

After the damaged blowout preventer is removed, a new BOP can beinstalled while the MPBPA below the BOP continues to collect thehydrocarbon flow through side branch 550. A device driver string 540 canbe mounted through the MPBPA above BOP 306. If a damaged BOP is removed,the MPBPA pre-installed between the well head and the BOP, can be usedto mount device driving string 540 from its main port 510 through thewell head while hydrocarbon flow is conducted through branch pipe 551.

A device running example is illustrated in FIG. 21. Well pluggingassembly 620 is mounted at the bottom of assembly driver string 640. Aretractable rotary cutting device 680 is mounted with the plug to millthrough possible debris. A monitoring and inspection device 630 ismounted above a plugging device 620. If pipe repair is required,expandable casing/pipe repair assembly 650 is mounted next up abovemonitoring and inspection device 630. Assembly driver string 640 islaunched through the MPBPA 600, and driven into a BOP tubular corechamber 690 through the assembly driver string port 610, BOP port 670,into the well. Devices are grapple mounted, and released and set atlocations. A tubing hanger 660 is located at sea floor 90. Sonic,ultrasonic, or electromagnetic emitters, transducers, or sensors can bedeployed to select strategic locations to study the condition of thewell casing, pipes, valves, seals and other well components. Devicedriving string 640 is mounted with repair components or assemblies tolocation, released, set, and inspected. The assembly device drivingstring 640 is then driven through the adaptor 200 down to an appropriatewell plugging location, one example being at the bottom of the well atreservoir level as in a “bottom kill,” and the plugging assemblyreleased and set. As stated above, alternatively, a drill pipe loadedwith cement and mounted through MPBPA 600 below blowout preventer 306can be lowered down to the bottom of the well and used to pump cement tothe bottom of the well to “bottom kill” the well. When there is adamaged pipe stuck inside the BOP core chamber 690, assembly devicedriver string 640 can be used to cut away obstruction, and remove thedamaged pipe out of BOP core chamber 690 and well bore casing pipe 665.

In case where a bore hole to casing or production tubing annulus seal isbroken, a retractable tube cutting device can be used to cut theproduction tube at the reservoir ceiling level in order to reach andre-seal the wellbore, reservoir, and production tube interface.Alternately, the Production-Can holes can be opened, and an assemblydrill pipe string passing through the adaptor is used to pump cementthrough the Production-Can holes to close the well and seal the wellbore to well pipe annulus.

FIG. 22 shows installation of MPBPA 500 above blowout preventer 306.Outside of a blowout event, there should be no hydrocarbon flow orpresence in the casing tube, in the BOP core chamber, nor in the MPBPAchamber outside of a production pipe. The presence of MPBPA 500 enablescomplete blowout hydrocarbon collection from above blowout preventer306, inspection and repair of blowout preventer 306, as well as accessto the wellbore through blowout preventer 306. An optional anchoringinfrastructure and support and protection platform 103 installed aboveblowout preventer 306 anchors and protects blowout preventer 306,blowout preventer 306 to MPBPA 500 connection 505, and operationslaunched through the upper MPBPA 500. Platform 103 can also be mountedon top of MPBPA 500 with a top flange 503 that sits atop platform 103 toalso protect MPBPA 500.

Blowout preventer as one used at Macondo Well is more than 5 times widerand 10 times taller than well head 303, and weights more than 300 tons.In conventional hydrocarbon well installations, there is no structuralsupport for the blowout preventer and its connections to the riser pipeand the well head. An explosion, an earthquake, a whale, or a fallenriser pipe can upset the vertical stack, causing the blowout preventerto lean and leak with no access to the well to close off the hydrocarbonflow and remove the endangered blowout preventer. Potentially theblowout preventer can fall after leaning for a prolonged period,breaking its connection to the well pipe and well head, or even takingout part of well head 303 and the well casing with it. The set up shownin FIG. 22 remedies these serious shortcomings.

FIG. 22 shows MPBPA 500 having optional hydrocarbon and pressuredetection and diversion system 710 installed between blowout preventer306 and well head 303. An optional structural support framework 760 ismounted across the bottom of blowout preventer 306 and anchored toanchoring piers 101 to further support and stabilize blowout preventer306 from below blowout preventer 306. A base plate 300 and well headbrace 305 supports and protects well head 303 and its connection tosystem 710. Details of base plate 300 and well head brace 305 are shownin FIG. 9. Base plate 300, with its large horizontal surface resting onthe seafloor is self anchoring. It can also be used to anchor BOP, aswell as help anchoring piers 101.

Particularly large and highly compressed methane gas bubbles mixed inwith oil rising from a methane rich reservoir into a well bore willquickly expand in volume and accelerate the rise to the rig causingexplosion and destroy equipment. It is also a precious resource that isburned off and wasted in conventional oil well operations. The problemsof conventional kick detection method and the reliability of theconventional BOP are discussed previously. In addition, even if a BOPsuccessfully rams and shears pipes within it and shuts off a highpressure blowout flow, the well and the earth formation beneath could beat risk. It is also extremely difficult and costly and maybe impossibleto unwind an activated BOP to recover the well. The embodiments belowprovide solutions to these problems.

Installing Multi-Port Branched Pipe Adaptor (MPBPA) 500 between wellhead 303 and blowout preventer 306 provides access to the well andcontrol to the hydrocarbon flow from below blowout preventer 306. Thiscapability is vital when blowout preventer 306 is malfunctioning,jammed, leaking or leaning. Closing valve 505 in MPBPA 500 enables saferemoval of a damaged or leaning blowout preventer. A MPBPA assemblyinstalled below blowout preventer 306 further enables inclusion of ahydrocarbon detection and management system 710 similar to system 440described in FIG. 15. System 710 is fitted with a pressure and/orhydrocarbon chemical sensor assembly 713 to directly detect and divertthreatening hydrocarbon kick to a distance away from the well for saferelease and storage, or to a separator 596 to separate oil and gas forseparate diversion and storage. Iris shutter valve 505 closes whensensor 713 detects an unexpected high up-flow pressure or hydrocarbonpresence. Diversion pipe 550 conducts the hydrocarbon kick flow to astorage unit 720 at a practical and safe distance as shown in FIG. 23.Storage unit 720 may be located on seafloor to accommodate temporarystorage during storage ship absence. Optional pipe support 730 is notneeded if flexible piping is used. Branch pipe control valve 555 can beused to control the hydrocarbon release rate into diversion pipe 550.Alternately, hydrocarbon (and/or pressure) sensor assembly 713 can becombined with a bleed valve 714 to control hydrocarbon release intodiversion pipe 550. Separator 596 separates gas collection from oilcollection. Separator 596 can be constructed with a sufficiently strongfilter that allows gaseous methane to pass, and filters out oil.Alternately, separator 596 can be incorporated into storage unit 720.Gravity separates the lighter gaseous methane to the upper part ofstorage unit toward its top, and oil sinks to the lower part of storageunit 720. Pipe 721 conducts methane away to a methane collectionfacility and pipe 722 conducts oil to an oil collection facility. Valves505 and 714 are centrally closing annular valves. They can beconstructed using iris shutter valves described later in FIG. 26 toaccommodate pipe presence inside valves 505 and 714. The details ofconstruct and operation of system 710 are similar to that described insystem 440. During production mode hydrocarbons flow upward through aproduction pipe mounted through the center of MPBPA main branch 520 andthe tubular core of BOP 306. There should be no legitimate hydrocarbonpresence in the annular space outside of the production pipe. System 710is as essential before and during production.

In FIG. 24 is shown a first line defense at the bottom of the wellboreagainst a high pressure hydrocarbon kick from surging upward into a wellsystem. An inner-most casing pipe 810 of the well system is fitted witha check valve 811 preventing up-flow as shown in an assembly 800. Casingpipes that reach the proximity of a hydrocarbon reservoir can each befitted with a centrally closing check valve to prevent roguehydrocarbons from entering it or annular space between the pipes.Similarly, in another assembly 802, a check valve 831 is fitted to thebottom of a drill pipe 830 to prevent hydrocarbons from entering upwardinto drill pipe 830. An assembly 804 shows a pipe 840 fitted with asensor controlled gate valve 841. These check valves close whenencountering an upward pressure preventing upward fluid flow, openproportionally when encountering downward pressure to allow downwardinsertion of fluid or objects. Check-valves 811 and 831 are constructedin a shutter plate manner. In response to an up flow pressure, a shutterclosing plate 812 for valve 811 and a shutter closing plate 832 forvalve 831 hung from hinges 814 and 834 respectively rise to close tightagainst a closing seat 816 for valve 811 and a closing seat 836 forvalve 831, preventing a high pressure hydrocarbon kick from surgingupward into pipes 810 and 830 above valve 811 and valve 831. Closingplates 812 and 832, or hinges 814 and 834 can be spring loaded such thatclosing plates 812 and 832 are normally at closed positions. Assembly804 shows a threshold pressure sensor or a hydrocarbon chemical sensor843 in combination with a sensor controlled gate valve 841 mounted to apipe 840 that also prevents hydrocarbon up-flow into pipe 840. Whensensor 843 detects a threshold pressure or hydrocarbons, sensor 843produces an output that drives gates 842 hung on hinges 844 to shutclose, and shut out the rogue hydrocarbon kick flow. Gates 842 andhinges 844 can also be set at a normally closed position by springloading. All three types of check valve illustrated in FIG. 24 can beused for all pipes or tubal members of an apparatus.

While all three valves in FIG. 24 can be used on any pipe, it ispreferable that the inner-most casing pipe of a well be fitted with atubal shutter check valve having the same outer diameter as shown in811. The passage way of check valve 811 should be close to the innerdiameter of casing pipe 810 and larger than the outer diameter of aproduction pipe (not shown), which is inserted inside casing pipe duringwell completion process for production. The geometry of the closingplate 812 and its seat 816 are shaped to fit this requirement. Thesmaller drilling pipe 830 (at 5.5″ OD and 3.5″ ID) places lessrestriction to the shape and size on check valve 831. A simple shuttercheck valve 831 as show in assembly 802 has a square cross section (orany other usable geometric shape, for example a hexagon), a flat closingplate 832 and closing seat 836 slightly larger than, and covering theinner diameter of drill pipe 830. Valve 831 needs to fit well within theinner most casing pipe 810, or fit within the production pipe if it isto be used inside the production pipe.

FIG. 25 illustrates various inner views of the workings of tubal shuttercheck valve 811 in assembly 800 shown in FIG. 24. A properly shapedclosing plate 812 hangs from hinge 814 mounted on a tubal wall locationcan be spring loaded at the hinge or from the tubal wall below the hingeto maintain a normally closed safety position against shaped ridge seat816 along the inner tubal wall of valve 811. When encountering a largeenough net downward pressure, the closing plate 812 opens downward.Upward pressure of a hydrocarbon kick pushes the closing plate eventighter against closing seat 816, securely shut off upward passage tothe casing pipe 810 above. Downward pressure from the insertion of aproduction pipe, a packer, a drill pipe, or other apparatus pushes downclosing plate 812 to open valve 811. At the fully open position, shapedclosing plate 812 hangs down and conforms to the tubal wall as shown intop view 850 and side view 851. Side view 852 shows the fully openposition of closing plate 812 at 90 degree angle from side view 851.Views 853 and 854 are side views 90 degrees from each other of closingplate 812 at closed position. View 855 shows the closing ridge seat 816along the inner tubal wall and closing plate 812 closing against ridgeseat 816, viewed at a 45 degree angle from views 853 and 854.

FIG. 26 shows a center closing iris shutter check valve 861. Properlyshaped closing blades 862 hang downward at a suitable angle from springloaded hinges 864 mounted in a circular ring around an inner parameterof iris shutter check valve 861. When encountering an upward hydrocarbonsurge, the blades rise to close tight toward the center of valve 861,closing off its flow path upward. When there is no pipe present insidevalve 861, the shutter blades close completely. Shutter blades 862 andhinges 864 can be spring loaded to a normally closed position. Valve 861can also be configured and controlled to be normally open to allow pipesand legitimate fluids such as drilling mud and seawater to pass through,and only closes to prevent unwanted flow, for example hydrocarbons.

Another way of constructing a centrally closing iris shutter valve isHorizontal blade iris shutter valve 865. Horizontally mounted closingblades 867 move toward the center to close, and retract into a bladechamber 869 surrounding the central passage to open. The horizontal irisshutter can be configured to be a two-way valve, or a one-way valve ofeither direction. The blades of a horizontal shutter valve can be set ata normally closed position or normally open as needed in differentapplications. Views 871, 873, 875 and 877 show top cross sectional viewsof a centrally closing valve at various degrees of closing (opening)positions. If a pipe is present inside shutter valve 861 or 865, theshutter blades close around the pipe.

When pre-installed in a well system as a part of a rogue hydrocarbondetection, management, and diversion system, control valves 202, 434,505, (and if present bleed valves 432 and 714) shown in FIGS. 3, 15 and22 are set to normally open, closing at detection of rogue hydrocarbonpresence. These are annular valves which close toward the center of theadaptor around an inside pipe if present. Horizontal or vertical bladeiris shutter valve as described in FIG. 26 can be used to constructthese valves. Side branch valves 206, 435, and 555 are normally closed,opening at detection of rogue hydrocarbon presence. Side branch valves206, 435 and 555 are normally closed to prevent legitimate fluids frombeing diverted and opened when sensors detecting rogue hydrocarbonpresence. Bleed valves 432, 594 and 714 if present, are partially closedto allow controlled hydrocarbon release to a diversion branch. Aproduction pipe can also be equipped with a threshold pressure or flowrate activated valve to protect against a hydrocarbon up flow exceedinga safety threshold pressure or flow rate. During production mode, a sidebranch in adaptor 200 and 500 can be used to relieve annular pressurebuild up between production casing pipe and production pipe, if apressure sensor is installed in the sensor assembly in the main branch.

Additional devices can be installed and used to provide information toanalysts and decision makers to enable timely and informed decisions.For example, embedded micro sensors, transducers, emitters such aspressure and temperature sensors, chemical sensors, sonic, ultra-sonic,or electromagnetic emitters and transducers can be mixed into anadhesive coating material and painted on well tube surfaces before thetubes are installed into the well. Such devices when installed detectwell status and transmit signals to monitoring stations or wirelessreceivers on an ROV. Alternatively, wired or wireless sensors, emitter,and transducers can be strategically mounted on select well tubelocations. These devices mounted in the well can provide information toanalysts and decision makers to enable timely and informed decisions.

The foregoing discussion discloses and describes merely exemplarymethods and embodiments. As will be understood by those familiar withthe art, the disclosed subject matter may be embodied in other specificforms without departing from the spirit or characteristics thereof.Accordingly, the present disclosure is intended to be illustrative, butnot limiting, of the scope of the invention, which is set forth in thefollowing claims.

1-51. (canceled)
 52. A well safety system, comprising: a blowoutpreventer placed over a well head; and, an anchored infrastructure thatprotects the well head and the blowout preventer.
 53. A well safetysystem as in claim 52 wherein the anchored infrastructure includesanchoring piers driven into the sea floor, the anchoring piers anchoringthe blowout preventer and the well head to the sea floor.
 54. A wellsafety system as in claim 52 wherein the anchored infrastructureincludes a pier anchoring disc and an anchoring pier, the anchoring pierbeing driven through a center hole of the pier anchoring disc into thesea floor.
 55. A well safety system as in claim 52 wherein the anchoredinfrastructure includes a platform above the blowout preventer, theplatform being anchored to the sea floor by anchoring piers.
 56. A wellsafety system as in claim 52 wherein the anchored infrastructureincludes a containment and protection chamber that covers the blowoutpreventer and the well head.
 57. A well safety system as in claim 52wherein the containment and protection chamber includes a hydrocarboncollection pipe adaptor.
 58. A well safety system as in claim 52 whereinthe anchored infrastructure includes a base plate located under theblowout preventer on the sea floor, the well head and the blowoutpreventer being anchored to the base plate.
 59. A well safety system asin claim 58 wherein the anchored infrastructure includes a blowoutpreventer support framework anchored to the base plate.
 60. A system forenhancing well safety, the system comprising: a well casing pipeequipped with a one-way check valve preventing hydrocarbon up flow intothe well casing pipe.
 61. A system as in claim 60, the one-way checkvalve is a tubal shutter plate check valve.
 62. A system as in claim 60,the one-way check valve is an iris shutter check valve.
 63. A system asin claim 60, the one-way check valve is constructed using a shutterplate.
 64. A system as in claim 60, the one-way check valve is a tubalshutter check valve.
 65. A system as in claim 60, the systemadditionally includes: a drill pipe equipped with the one-way checkvalve preventing hydrocarbon up flow into the drill pipe.
 66. A systemas in claim 65, the system additionally includes: a production pipeequipped with a safety valve, which reduces its opening when detecting aflow above a safety threshold.